Systems and Methods of Securing and Protecting Wellbore Control Lines

ABSTRACT

Disclosed are systems and method of securing and pro-tecting control lines during run-in into a wellbore with wellbore tape. The wellbore tape includes a substrate having a front surface and a back surface, a wear-resistant coating disposed on at least a portion of the front surface, and an adhesive layer disposed on the back surface, the adhesive layer being configured to affix the substrate to an outer surface of a conveyance.

BACKGROUND

The present disclosure relates to wellbore operations and, moreparticularly, to securing and protecting control lines during run-ininto a wellbore.

In the oil and gas industry, strings of pipe are typically run into awellbore at various times during the creation and completion of a well.A wellbore is formed for example, by running a bit on the end of thetubular string of drill pipe. Later, larger diameter pipe is run intothe wellbore and cemented therein to line the well and isolate certainparts of the wellbore from other parts. Smaller diameter tubular stringsare then run through the lined wellbore either to form a new length ofwellbore therebelow, to carry tools into the well, or to serve as aconduit for hydrocarbons gathered from the well during productionoperations.

Some of the tools that are run into the wellbore are used for remoteoperation or communication in the downhole environment. Some of thesetools are operated mechanically by causing one part to move relative toanother. Others are operated using natural forces like differentialsbetween downhole pressure and atmospheric pressure. Others are operatedhydraulically by adding pressure to a column of fluid in the tubularabove the tool. Still others need a control line to provide either asignal, power, or both in order to operate the device or to serve as aconduit for communications between the device and the surface of thewell. Control lines, also known as umbilical cords, can provideelectrical, hydraulic, or fiber optic means of signal transmission,control, and power into the downhole environment.

Because the interior of a tubular string is generally kept clear formovement of fluids and other devices therein, control lines are mosttypically run into the well along the outer surface of the tubularstring. For example, a tubular string may be formed at the surface of awell and, as it is progressively inserted into the wellbore, a controlline may be introduced into the wellbore simultaneously with the tubularstring. The control line is typically provided from a reel or spoolsomewhere near the surface of the well and extends along the tubularstring to some component attached to the string. Because of the harshconditions and non-uniform surfaces in the wellbore, control lines aretypically fixed to the tubular string along is entire length to keep theline and the tubular string together and prevent the control line frombeing damaged or pulled away from the tubular string during its tripinto the well.

Control lines are typically attached to the tubular strings using clampsplaced at predetermined intervals along the length of the tubular stringby an operator. These clamps are usually metal or polymeric protectorsthat mechanically bolt, clamp, or otherwise fasten the control line tothe tubular. These bolt-on protectors, however, are expensive and bulky,and several different sizes of protectors may need to be on-hand on therig floor to accommodate varying changes in tubular diameter. Moreover,such bolt-on protectors can require several assembly tools that furthercomplicate the process of attaching control lines to the tubularstrings.

SUMMARY OF THE DISCLOSURE

The present disclosure relates to wellbore operations and, moreparticularly, to securing and protecting control lines during run-ininto a wellbore.

In some embodiments, a wellbore tape is disclosed and may include asubstrate having a front surface and a back surface, a wear-resistantcoating disposed on at least a portion of the front surface, and anadhesive layer disposed on the back surface, the adhesive layer beingconfigured to affix the substrate to an outer surface of a wellboreconveyance remain adhered to the wellbore conveyance in a wellboreenvironment.

In other embodiments, a well system is disclosed and may include aconveyance extendable into a wellbore, at least one control lineextending externally to the conveyance, and a length of wellbore tapewrapped at least partially around the conveyance and attaching the atleast one control line thereto, the wellbore tape including a substratehaving a front surface with a wear-resistant coating disposed on atleast a portion thereof and a back surface with an adhesive layerdisposed thereon, and the adhesive layer being configured to affix thesubstrate to an outer surface of the conveyance and remain adhered tothe wellbore conveyance in a wellbore environment.

In yet other embodiments, a method is disclosed that may includeintroducing a wellbore conveyance into a wellbore, arranging at leastone control line external to the wellbore conveyance, and attaching theat least one control line to the wellbore conveyance with a length ofwellbore tape wrapped at least partially around the wellbore conveyance,the wellbore tape including a substrate having a front surface with awear-resistant coating disposed on at least a portion thereof, and aback surface with an adhesive layer disposed thereon.

The features of the present disclosure will be readily apparent to thoseskilled in the art upon a reading of the description of the embodimentsthat follows.

BRIEF DESCRIPTION OF THE DRAWINGS

The following figures are included to illustrate certain aspects of thepresent disclosure, and should not be viewed as exclusive embodiments.The subject matter disclosed is capable of considerable modifications,alterations, combinations, and equivalents in form and function, as willoccur to those skilled in the art and having the benefit of thisdisclosure.

FIG. 1 illustrates a exemplary well system that may employ one or moreprinciples of the present disclosure, according to one or moreembodiments.

FIGS. 2A and 2B illustrate a length of exemplary wellbore tape,according to one or more embodiments.

FIG. 3 illustrates an isometric view of a control line as coupled to aconveyance using a length of exemplary wellbore tape, according to oneor more embodiments.

FIG. 4A illustrates a cross-sectional end view of a system forinstalling exemplary wellbore tape, according to one or moreembodiments.

FIG. 4B illustrates an isometric view of a portion of the system of FIG.4A.

FIG. 4C illustrates an exemplary application of the system of FIG. 4A,according to one or more embodiments.

DETAILED DESCRIPTION

The present disclosure relates to wellbore operations and, moreparticularly, to securing and protecting control lines during run-ininto a wellbore.

The systems and methods disclosed herein provide a low-cost andefficient means of securing control lines to wellbore conveyances beingrun downhole, and simultaneously protecting the control lines fromdamage during run-in. In particular, disclosed is a wellbore tape thatmay be coated with, or otherwise have affixed thereto, an abrasion- orwear-resistant material. The wellbore tape may be wrapped at leastpartially around a wellbore conveyance, thereby securing a control lineto the wellbore conveyance and simultaneously providing protection tothe control line as the wellbore conveyance is introduced downhole. Thewellbore tape is not dependent on tubing size, coupling length, thenumber of control lines, or the tubing material or type, and thereforemay prove advantageous from a standardized inventory perspective.Moreover, the time required to install the wellbore tape may bedrastically shorter than traditional bolt-on clamping systems, therebysaving valuable rig time. The wellbore tape may prove particularlyadvantageous in lower-cost, low-tech well installations such asunconventional wells requiring chemical injection, artificial lift, oroperations for attaching additional control lines to existing tubing orpower cables.

Referring to FIG. 1, illustrated is a well system 100 that may embody orotherwise employ one or more principles of the present disclosure,according to one or more embodiments. As illustrated, the well system100 may include a service rig 102 that is positioned on the earth'ssurface 104 and extends over and around a wellbore 106 that penetratesone or more subterranean formations 108. The service rig 102 may be adrilling rig, a completion rig, a workover rig, or the like. In someembodiments, the service rig 102 may be omitted and replaced with astandard surface wellhead completion or installation. Moreover, whilethe well system 100 is depicted as a land-based operation, it will beappreciated that the principles of the present disclosure could equallybe applied in any sea-based or sub-sea application where the service rig102 may be a floating platform or sub-surface wellhead installation, asgenerally known in the art.

The wellbore 106 may be drilled into the subterranean formation 108using any suitable drilling technique and may extend in a substantiallyvertical direction away from the earth's surface 104 over a verticalwellbore portion 110. At some point in the wellbore 106, the verticalwellbore portion 110 may deviate from vertical relative to the earth'ssurface 104 and transition into a substantially horizontal wellboreportion 112. In some embodiments, the wellbore 106 may be completed bycementing a casing string 114 within the wellbore 106 along all or aportion thereof.

The system 100 may further include a downhole tool 116 configured to beconveyed into the wellbore 106 in order to perform one or more wellboreoperations. As illustrated, the downhole tool 116 may be conveyed intothe wellbore 106 as coupled or otherwise attached to a wellboreconveyance 118 that extends from the service rig 102. The conveyance 118may be, but is not limited to, drill string or pipe, production tubingor pipe, coiled tubing, chemical injection lines, power cables, or anyother rigid or semi-rigid tubular or string of tubulars that can beinserted into the wellbore 106.

One or more control lines 120 may be coupled or otherwise attached tothe outer surface of the conveyance 118 as it is being introduced intothe wellbore 106. Although only one control line 120 is depicted in FIG.1, it will be appreciated that any number of control lines 120 may beattached to the exterior of the conveyance 118, without departing fromthe scope of the disclosure. The control line 120 may be representativeof or otherwise include one or more hydraulic lines, one or moreelectrical lines, one or more fiber optic lines, or other types ofcontrol lines known to those skilled in the art. Accordingly, the term“control line” as used herein may broadly refer to any tubular structureor line coupled to the exterior of the conveyance 118.

As illustrated, the control line 120 may extend externally to theconveyance 118 until being communicably coupled to the downhole tool 116at its distal end. The control line 120 may be configured tocommunicably couple the downhole tool 116 to the service rig 102, suchthat power may be provided to various downhole equipment associated withthe downhole tool 116. The control line 120 may also be used as abi-directional communication line configured to convey command signalsand otherwise transmit data between the downhole tool 116 and theservice rig 102.

According to embodiments of the present disclosure, the control line 120may be coupled or otherwise attached to the exterior of the conveyance118 using a wellbore tape 122. The wellbore tape 122 may be installed onthe conveyance 118 at the service rig 102 by rig hands or other workersas the conveyance 118 is introduced systematically into the wellbore106. The wellbore tape 122 may be installed at several locations alongthe axial length of the conveyance 118 in order to attach the controlline 120 to the conveyance 118 at corresponding discrete locations. Forexample, the wellbore tape 122 is depicted in FIG. 1 as wellbore tape122 a, 122 b, 122 c, and 122 d. In some embodiments, the respectivelocations of the wellbore tape 122 a-d may be spaced at predetermineddistances from each other. In other embodiments, the locations of thewellbore tape 122 a-d may be spaced randomly, without departing from thescope of the disclosure. In at least one embodiment, the wellbore tape122 a-d may be installed on the conveyance 118 once or twice per jointof the conveyance 118.

Installing the wellbore tape 122 may include wrapping or otherwiseextending the wellbore tape 122 around at least a portion of the outercircumferential surface of the conveyance 118 and simultaneouslycapturing a portion of the control line 120 at that particular location.As discussed below, the wellbore tape 122 may be adhered to or otherwisestuck to the outer surface of the conveyance 118 as it is wrapped.Moreover, the wellbore tape 122 may have an abrasion- or wear-resistantcoating or material applied to its outer surface which may serve toprotect the control line 120 from abrasion or damage as the conveyance118 is introduced downhole. Accordingly the wellbore tape 122 isconfigured to be installed in a short time frame on the floor of theservice rig 102 and provide protection to the control line 120.

Referring now to FIGS. 2A and 2B, with continued reference to FIG. 1,illustrated is a length of exemplary wellbore tape 122, according to oneor more embodiments. In particular, FIG. 2A illustrates a top view ofthe exemplary wellbore tape 122 and FIG. 2B illustrates a side view ofthe exemplary wellbore tape 122. While only a short length or portion ofthe wellbore tape 122 is shown, it will be appreciated that the wellboretape 122 may extend in either direction (i.e., to the left and/or rightin FIGS. 2A and 2B) to lengths depending at least partially on cost andmanufacturing capabilities.

As illustrated, the wellbore tape 122 may include a substrate 202 havinga front surface 204 a and a back surface 204 b. A wear-resistant coating206 may be disposed on or otherwise applied to all or a portion of thefront surface 204 a and an adhesive layer 208 may be disposed on orotherwise applied to the back surface 204 b. The substrate 202 may bemade of a variety of materials and/or compositions including, but notlimited to, plastics or polymers, composites, elastomers, woven fabrics,metal foils, combinations thereof, and the like. In some embodiments,the material of the substrate 202 may be cured to a hardened or rigidstate after or while the wellbore tape 122 is being applied to theconveyance 118. In such embodiments, curing of the substrate 202 may beaccomplished through the application of at least one of ultravioletradiation, electron beam radiation, a chemical catalyst, or heat inorder to help facilitate the hardening process.

Suitable plastics or polymers that may be used for the substrate 202include, but are not limited to, polyamides, polyimides, acetalcopolymers, polybenzimidazoles, polyetheretherketones (PEEK),polyetherimides, nylons, polyesters, polysulphones,polyphenylenesulphones, polyphenylene sulphides, acrylate polymers,acrylic resins, polymethylmethacralytes, polycarbonates,polyvinylchlorides (PVC), polyviylidenefluorides,polytetrafluoroethylenes (PTFE), polyethylenes, polypropylenes, glassepoxies, glass silicones, epoxy resins, phenol resins,polybenzoimidazole resins, benzoxazine resins, cyanate ester resins,unsaturated polyester resins, vinyl ester resins, urea resins, melamineresins, bismaleimide resins, polyimide resins and polyamideimide resins,polyolefin resins, styrene-based resins, polyoxymethylene resin,polyamide resins, polyurethane resins, polyurea resins,polydicyclopentadidene resin, polycarbonate resins, polymethylenemethacrylate resin, polyetherimide resins, polysulfone resins,polyallylate resins, polyether sulfone resins, polyketone resins,polyether ketone resins, polyether ether ketone resins, polyether ketoneketone resins, polyarylate resins, polyether nitrile resins, polyimideresins, polyamideimide resins, phenol resins, phenoxy resins,fluorine-based resins such as polytetrafluoroethylene resin, elastomers(e.g., butadiene acrylonitrile, its carboxylic acid or aminemodification products, fluoroelastomers, polysiloxane elastomers),rubbers (butadiene, styrene butadiene, styrene butadiene styrene,styrene isoprene styrene, natural rubber, etc.), resins for RIM (e.g.,those containing a catalyst or the like capable of forming polyamide 6,polyamide 12, polyurethane, polyurea or polycicyclopentadiene), cyclicoligomers (those containing a catalyst or the like capable of forming apolycarbonate resin, polybutylene terephthalate resin, etc.), thecopolymers and modification products thereof, resins or plasticsobtained by blending two or more of the foregoing, and the like.

Suitable composite materials that may be used for the substrate 202include, but are not limited to, any of the aforementioned plastics orpolymers reinforced with carbon fiber, carbon nanotubes, glass fibers,fiberglass, polymer fibers (e.g., KEVLAR®), metal fibers, ceramicfibers, combinations thereof, and the like. The composite materials maybe used to not only provide reinforcement to the substrate 202, but alsofor purposes of thermal or electrical conductivity if need be.

Suitable elastomers that may be used for the substrate 202 include, butare not limited to, natural polyisoprene, synthetic polyisoprene,polybutadiene, chloroprene rubber, polychloroprene, neoprene, baypren,butyl rubber, halogenated butyl rubbers, styrene-butadiene rubber,nitrile rubber (e.g., hydrogenated nitrile rubbers (HNBR) Therban andZetpol), ethylene propylene rubber, ethylene propylene diene rubber,epichlorohydrin rubber, polyacrylic rubber, silicone rubber,fluorosilicone rubber, fluoroelastomers, perfluoroelastomers, polyetherblock amides, chlorosulfonated polyethylene, ethylene-vinyl acetate,thermoplastic elastomers, resilin, elastin, polysulfide rubber,combinations thereof, and the like.

Suitable threads or fill yarn for woven fabrics that may be used for thesubstrate 202 include, but are not limited to, cotton, polyester, nylon,rayon, fiberglass, combinations thereof, and the like.

The wear-resistant coating 206 may also be made of a variety ofmaterials or compositions including, but not limited to, ceramics,elastomers, plastics or polymers, metals, glass beads, crystallinematerials (natural or manmade), combinations thereof, and the like.Suitable elastomers that may be used for the wear-resistant coating 206are substantially similar to those materials suitable for the substrate202 and therefore will not be listed again. Similarly, suitable plasticsor polymers that may be used for the wear-resistant coating 206 aresubstantially similar to those materials suitable for the substrate 202and therefore will also not be listed again.

In some embodiments, where metal is used as the wear-resistant coating206, the metal material may be impregnated with oil or another lubricantsuch that the wear-resistant coating 206 may exhibit a degree oflubricity and otherwise reduce friction. Similarly, the use ofelastomers as the wear-resistant coating 206 may prove advantageoussince fluids encountered in the wellbore 106 may develop thin fluidfilms on the wear-resistant coating 206 that may serve to reducefriction. In some embodiments, any of the materials used for thewear-resistant coating 206 may be coated or otherwise impregnated withTEFLON® in order to reduce friction.

The adhesive layer 208 may encompass any known adhesive or adhesivesystem including, but not limited to, natural rubber-based adhesives,synthetic rubber-based adhesives, silicone adhesives, polyacrylateadhesives, pressure-sensitive adhesives, solvent based adhesives,polymer dispersion adhesives, contact adhesives, reactive adhesives,heat activated adhesives, combinations thereof, and the like. Similar tothe substrate 202, the adhesive layer 208 may optionally be cured to ahardened or rigid state after or while the wellbore tape 122 is beingapplied to the conveyance 118. Curing of the adhesive layer 208 may beaccomplished through the application of at least one of ultravioletradiation, electron beam radiation, a chemical catalyst, or heat. Inother embodiments, the adhesive layer 208 may be omitted from thewellbore tape 122 altogether. Instead an adhesive or glue may be applieddirectly to the outer surface of the conveyance 118 and the substrate202 may be applied to the adhesive, without departing from the scope ofthe disclosure. The adhesive or adhesive system that makes up theadhesive layer 208 may be configured to remain adhered to a wellboreconveyance 118 or control line 120 when exposed to downhole wellboreenvironments which may exhibit elevated temperatures and pressures.

The wear-resistant coating 206 may be bonded to the front surface 204 aof the substrate 202 using one or more of the adhesives listed abovewith reference to the adhesive layer 208. In some embodiments, thewear-resistant coating 206 may be applied to the entire front surface204 a of the substrate 202. In other embodiments, however, thewear-resistant coating 206 may be applied to the front surface 204 a insections, portions, or strips, without departing from the scope of thedisclosure. Applying the wear-resistant coating 206 in sections,portions, or strips may prove advantageous in reducing material andmanufacturing costs of the wellbore tape 202.

As illustrated in FIGS. 2A and 2B, the wear-resistant coating 206 may beapplied to the front surface 204 a of the substrate 202 inlaterally-spaced strips or portions (i.e., four strips shown). In someembodiments, each strip of wear-resistant coating 206 may beequidistantly spaced from each other. In other embodiments, the stripsof wear-resistant coating 206 may be randomly spaced from each otheralong the length of the wellbore tape 122, without departing from thescope of the disclosure.

In some embodiments, one or more of the strips of the wear-resistantcoating 206 may be arranged orthogonal 210 to the lateral edges of thewellbore tape 202 (i.e., the upper and lower edges of the substrate 202as seen in FIG. 2A). In other embodiments, however, as depicted in FIG.2A, one or more of the strips of the wear-resistant coating 206 may bearranged at an angle 212 slightly offset from orthogonal 210, withoutdeparting from the scope of the disclosure. The angle 212 may rangeanywhere from a few degrees to several degrees offset from orthogonal210. For instance, the angle 212 may be about 1°, about 5°, about 10°,about 20°, or about 45° offset from orthogonal 210, or any angletherebetween. In yet other embodiments, the angle 212 may be more than45° offset from orthogonal 210.

In the embodiment depicted in FIGS. 2A and 2B, the wear-resistantcoating 206 may be made of a ceramic material. In particular, thedepicted wear-resistant coating 206 encompasses several small ceramictiles bonded to the front surface 204 a of the wellbore tape 122. Thetiles may be small enough such that the wellbore tape 122 is able towrap around and otherwise generally conform to the circular shape of theconveyance 118. In some embodiments, for example, each ceramic tile maybe sized to about 1 mm by about 1 mm, about 5 mm by about 5 mm, about 10mm by about 10 mm, about 20 mm by about 20 mm, and larger sizes.

In some embodiments, the tiles may be square, as illustrated. In otherembodiments, however, one or more of the tiles may exhibit otherpolygonal shapes (e.g., triangle, rectangle, pentagon, hexagon,heptagon, octagon, etc.) or may exhibit a generally rounded or arcuateshape (e.g., circular, oval, elliptical, crescent, etc.), withoutdeparting from the scope of the disclosure. Those skilled in the artwill readily appreciate that the respective size and geometry of eachceramic tile may vary depending on several factors including wellboregeometry, geometry of the conveyance, manufacturing costs, and the costof materials. Accordingly, tiles of any size or geometry arespecifically contemplated herein as an integral part of this disclosure.

Referring particularly to FIG. 2B, in some embodiments, one or both ofthe longitudinal ends 214 of the strips of the wear-resistant coating206 may be angled or otherwise beveled such that no perceptible edge ofthe coating 206 is apparent on its lateral edges. Having such beveledends 214 may prove advantageous in reducing the likelihood that thewear-resistant coating 206 will be caught up on wellbore obstacles, suchas locating profiles or other angled surfaces or obstructions, andinstead smoothly transition over such obstacles.

The wear-resistant coating 206 may also exhibit a height 216 configuredto provide a standoff distance between the casing string 114 (FIG. 1)and the conveyance 118 during run-in. Such a standoff distance may proveadvantageous in protecting the conveyance 118 and the control line 120from detrimental wear against the interior of the casing string 114,especially around curves within the wellbore 106 (FIG. 1) where thediameter of the wellbore 106 often changes and could potentially damagethe control line 120. In such cases, the wear-resistance coating 206 mayfunction somewhat like a centralizer, as known by those skilled in theart. In some embodiments, multiple layers of the wellbore tape 122 maybe wrapped at a single location, thereby effectively increasing theheight 216 of the wear-resistant coating 206.

The particular height 216 of the wear-resistant coating 206 may vary,depending on the application and the particular geometry of the wellbore106. The height may be about 1 mm, about 5 mm, about 10 mm, about 20 mm,or any measurement therebetween. As will be appreciated, in someembodiments the height 216 may be less than 1 mm or larger than 20 mm,without departing from the scope of the disclosure. As will beappreciated, the height 216 may prove advantageous in preventing directimpact or pinching of the control line 120 by providing a stand-off orradial gap between the inner diameter of the casing string 114 and theouter diameter of the conveyance 118. Consequently, the height 216 mayessentially create an effective “safe zone” in which the control line120 will be held.

Referring again to FIG. 2A, the wellbore tape 122, or the substrate 202,may be manufactured to exhibit a particular width 218. As will beappreciated, the size of the width 218 may depend on material andmanufacturing capabilities, but also on the ability for a rig hand tohandle and install the wellbore tape 122 effectively. In someembodiments, for example, the width 218 of the wellbore tape 122 may beabout 2 inches. In other embodiments, the width 218 of the wellbore tape122 may be greater or less than 2 inches, such as about 1 inch, about 3inches, about 5 inches, and greater than 5 inches, without departingfrom the scope of the disclosure.

Referring now to FIG. 3, with continued reference to FIGS. 1 and 2A-2B,illustrated is an isometric view of a control line 120 as coupled to aportion of the conveyance 118 using a length of the exemplary wellboretape 122, according to one or more embodiments. Similar to theembodiment shown in FIGS. 2A-2B, the wear resistant coating 206 isapplied on the wellbore tape 122 in laterally-spaced strips. As brieflymentioned above, the wellbore tape 122 may extend or wrap around aportion or the entirety of the outer circumferential surface of theconveyance 118 in order to capture the control line 120 and otherwisesecure the control line 120 to the conveyance 118. In some embodiments,the wellbore tape 122 may be extended or wrapped around the outersurface of the conveyance and adhered or otherwise affixed to itselfusing the adhesive layer 208 (FIG. 2B).

In some embodiments, as illustrated, the wellbore tape 122 may beinstalled on the conveyance 118 at an angle 302 offset from orthogonal306 to the longitudinal axis 304 of the conveyance 118. Installing thewellbore tape 122 at an angle 302 may prove advantageous by helping tofacilitate the external diameter of the wellbore tape 122 to work overany ledges or shoulders, such as small casing lips, upsets, or smalldebris, within the wellbore 106 as the conveyance 118 is rotated andadvanced.

The angle 302 may range anywhere from a few degrees to several degreesoffset from orthogonal 306. For instance, the angle 302 may be about 1°,about 5°, about 10°, about 20°, or about 45° offset from orthogonal tothe longitudinal axis 304, or any angle therebetween. In yet otherembodiments, the angle 302 may be more than 45° offset from orthogonalto the longitudinal axis 304. Those skilled in the art, however, willreadily appreciate that the wellbore tape 122 may nonetheless be appliedto the conveyance 118 as substantially aligned with orthogonal 306 tothe longitudinal axis 304, without departing from the scope of thedisclosure. Moreover, in at least one embodiment, the wellbore tape 122may be applied to the conveyance 118 longitudinally, such as beingaligned generally with the longitudinal axis 304.

Referring now to FIGS. 4A-4C, with continued reference to the priorfigures, illustrated is an exemplary system 400 for installing thewellbore tape 122, according to one or more embodiments. In particular,FIG. 4A illustrates a cross-sectional end view of the system 400, FIG.4B illustrates an isometric view of a portion of the system 400, andFIG. 4C illustrates an exemplary application of the system 400,according to one or more embodiments. As depicted in FIG. 4A, the system400 may include the wellbore tape 122 arranged about the conveyance 118and a relief insert 402 configured to house or otherwise receive thecontrol line 120. For clarity, the wear-resistant coating 206 applied tothe substrate 202 is not shown in FIGS. 4A-4C.

The relief insert 402 may generally be characterized as a ramp-likestructure configured to elevate the control line 120 off of the outersurface or outer diameter of the conveyance 118. As best seen in FIG.4B, the relief insert 402 may define a groove or channel 404 configuredto seat the control line 120 as it extends axially along the conveyance118. The relief insert 402 may define or otherwise provide opposing rampportions 406 a and 406 b that lead to a top surface 408 in which thechannel 404 may be formed or otherwise defined. The opposing rampportions 406 a,b and the top surface 408 may all be configured toreceive and otherwise seat a length of the wellbore tape 122. Asdepicted, the wellbore tape 122 may be configured to contiguously followup and back down the ramp portions 406 a,b and extend over the topsurface 408 to thereby secure the control line 120 within the channel404 and otherwise prevent its removal therefrom. The ramp portions 406a,b provide a relatively smooth transition for the wellbore tape 122between the outer surface of the conveyance 118 to the top surface 408of the relief insert 402.

In some embodiments, the system 400 may further include a vibrationdampener 410 arranged between the relief insert 402 and the outersurface of the conveyance 118. The vibration dampener 410 may be made ofa variety of materials used to dampen vibrations originating orotherwise propagating in the conveyance 118 and potentiallytransmittable to the control line 120. Use of the vibration dampener 410may be configured to reduce or eliminate such damaging vibrations bydecoupling the control line 120 from vibrations propagating through theconveyance 118 or substantially changing the vibration frequency. Inother aspects, the vibration dampener 410 may be used to provide anadded amount of cushion to the control line 120 such that it is lesssusceptible to being crushed upon being forced against the inner wall ofthe casing string 114 (FIG. 1) during run-in operations.

Referring particularly to FIG. 4C, one or more relief inserts 411 may beused to elevate the control line 120 off of the outer surface or outerdiameter of the conveyance 118, according to one or more embodiments.The relief inserts 411 may be similar in some respects to the reliefinsert 402 of FIGS. 4A and 4B. For instance, the relief inserts 411 maybe used receive and elevate the control line 120 off of the outerdiameter of the conveyance 118. Several lengths of wellbore tape 122 areshown in FIG. 4C, depicted as wellbore tapes 122 e, 122 f, 122 g, and122 h. Again, for clarity the wear-resistant coating 206 of the wellboretapes 122 e-h is not shown in FIG. 4C, but those skilled in the art willreadily appreciate that one or all of the wellbore tapes 122 e-h mayhave the wear-resistant coating 206 applied thereto. 411

The first and fourth wellbore tapes 122 e and 122 h may be applied tothe conveyance 118 in a manner substantially similar to the embodimentshown in FIG. 3. Accordingly, the wellbore tapes 122 e,h may be wrappedat least partially around the conveyance 118 and secure the control line120 in close engagement to the outer surface of the conveyance 118.

The second and third wellbore tapes 112 f and 122 g, however, may eachbe applied to the conveyance 118 in conjunction with a correspondingrelief insert 411, as generally described above. The control line 120may extend through or otherwise be received within the correspondingchannels 404 defined in each relief insert 411. As a result, the controlline 120 may be elevated off of the outer circumferential surface of theconveyance 118 and otherwise capable of longitudinally bypassing one ormore conveyance obstructions 412 associated with the conveyance 118. Insome embodiments, the conveyance obstruction 412 may be a cross couplingthat extends radially outward from the outer surface of the conveyance118. In other embodiments, the conveyance obstruction 412 may be adownhole tool or the like that exhibits an increased outer diameter ascompared to the conveyance 118. It will be appreciated that the reliefinserts 411 may have varying heights to accommodate the varying radialheights of potential conveyance obstructions 412.

Without properly transitioning the control line 120 from the outersurface of the conveyance 118 to a radial height that matches or exceedsthe radial height of the conveyance obstruction 412, the control line120 could potentially be damaged or otherwise crushed between the innerwall of the casing string 114 (FIG. 1) and the conveyance obstruction412. In another aspect, the control line 120 may potentially damage theconveyance obstruction 412 unless a sufficient standoff distance isfacilitated by the relief inserts 402.

Those skilled in the art will readily appreciate the several advantagesthat the wellbore tape 122 may provide. The wellbore tape 122encompasses a quick and efficient means of attaching the control line120 to the conveyance 118 and may be manufactured and installed to adesired strength and height to protect the control line 120 fromabrasion during run-in operations. As discussed above, the wellbore tape122 may be constructed of materials exhibiting sufficient strength and asuitable adhesive to maintain the integrity of the wrap. Use of thewellbore tape 122 eliminates the need for multiple control lineconnectors of multiple sizes designed for a particular job or set ofcontrol lines 120, thereby simplifying the process of attaching controllines 120 to conveyances 118.

Therefore, the disclosed systems and methods are well adapted to attainthe ends and advantages mentioned as well as those that are inherenttherein. The particular embodiments disclosed above are illustrativeonly, as the teachings of the present disclosure may be modified andpracticed in different but equivalent manners apparent to those skilledin the art having the benefit of the teachings herein. Furthermore, nolimitations are intended to the details of construction or design hereinshown, other than as described in the claims below. It is thereforeevident that the particular illustrative embodiments disclosed above maybe altered, combined, or modified and all such variations are consideredwithin the scope and spirit of the present disclosure. The systems andmethods illustratively disclosed herein may suitably be practiced in theabsence of any element that is not specifically disclosed herein and/orany optional element disclosed herein. While compositions and methodsare described in terms of “comprising,” “containing,” or “including”various components or steps, the compositions and methods can also“consist essentially of” or “consist of” the various components andsteps. All numbers and ranges disclosed above may vary by some amount.Whenever a numerical range with a lower limit and an upper limit isdisclosed, any number and any included range falling within the range isspecifically disclosed. In particular, every range of values (of theform, “from about a to about b,” or, equivalently, “from approximately ato b,” or, equivalently, “from approximately a-b”) disclosed herein isto be understood to set forth every number and range encompassed withinthe broader range of values. Also, the terms in the claims have theirplain, ordinary meaning unless otherwise explicitly and clearly definedby the patentee. Moreover, the indefinite articles “a” or “an,” as usedin the claims, are defined herein to mean one or more than one of theelement that it introduces. If there is any conflict in the usages of aword or term in this specification and one or more patent or otherdocuments that may be incorporated herein by reference, the definitionsthat are consistent with this specification should be adopted.

The invention claimed is:
 1. A well bore tape, comprising: a substratehaving a front surface and a back surface; a wear-resistant coatingdisposed on at least a portion of the front surface; and an adhesivelayer disposed on the back surface, the adhesive layer being configuredto affix the substrate to an outer surface of a wellbore conveyanceremain adhered to the wellbore conveyance in a wellbore environment. 2.The wellbore tape of claim 1, wherein the substrate is made of amaterial selected from the group comprising a plastic or polymer, acomposite, an elastomer, a woven fabric, and a metal foil.
 3. Thewellbore tape of claim 2, wherein the material is cured by applying atleast one of ultraviolet radiation, electron beam radiation, chemicalcatalysts, or heat to the material.
 4. The wellbore tape of claim 1,wherein the wear-resistant coating is made of a material selected fromthe group consisting of a ceramic, an elastomer, a plastic or polymer, ametal, crystalline materials, and glass beads.
 5. The wellbore tape ofclaim 1, wherein the adhesive layer comprises: an adhesive selected fromthe group consisting of natural rubber-based adhesives, syntheticrubber-based adhesives, silicone adhesives, polyacrylate adhesives,pressure-sensitive adhesives, solvent-based adhesives, polymerdispersion adhesives, contact adhesives, or reactive adhesives.
 6. Thewellbore tape of claim 1, wherein the wear-resistant coating is arrangedin laterally-spaced strips on the front surface of the substrate.
 7. Thewell bore tape of claim 6, wherein one or more of the laterally-spacedstrips is arranged at an angle offset from orthogonal to at least oneedge of the substrate.
 8. The wellbore tape of claim 1, wherein thewear-resistant coating comprises a plurality of ceramic tiles bonded tothe front surface of the substrate.
 9. The wellbore tape of claim 1,wherein the wear-resistant coating exhibits a height that provides astandoff distance between a casing string and the wellbore conveyance.10. A well system, comprising: a conveyance extendable into a wellbore;at least one control line extending externally to the conveyance; and alength of wellbore tape wrapped at least partially around the conveyanceand attaching the at least one control line thereto, the wellbore tapeincluding a substrate having a front surface with a wear-resistantcoating disposed on at least a portion thereof and a back surface withan adhesive layer disposed thereon, and the adhesive layer beingconfigured to affix the substrate to an outer surface of the conveyanceand remain adhered to the wellbore conveyance in a wellbore environment.11. The well system of claim 10, wherein the substrate is made of amaterial selected from the group consisting of a plastic or polymer, acomposite, an elastomer, a woven fabric, and a metal foil.
 12. The wellsystem of claim 11, wherein the material is cured by applying at leastone of ultraviolet radiation, electron beam radiation, chemicalcatalysts, or heat to the material.
 13. The well system of claim 10,wherein the wear-resistant coating is made of a material selected fromthe group consisting of a ceramic, an elastomer, a plastic or polymer, ametal, crystalline materials, and glass beads.
 14. The well system ofclaim 10, wherein the adhesive layer comprises an adhesive selected fromthe group consisting of natural rubber-based adhesives, syntheticrubber-based adhesives, silicone adhesives, polyacrylate adhesives,pressure-sensitive adhesives, solvent-based adhesives, polymerdispersion adhesives, contact adhesives, and reactive adhesives.
 15. Thewell system of claim 10, wherein one or more of the laterally-spacedstrips is arranged at an angle offset from orthogonal to at least oneedge of the substrate.
 16. The well system of claim 10, wherein thesubstrate is made of a material selected from the group comprising aplastic or polymer, a composite, an elastomer, a woven fabric, and ametal foil.
 17. The well system of claim 10, wherein the wear-resistantcoating is made of a material selected from the group consisting of aceramic, an elastomer, a plastic or polymer, a metal, and glass beads.18. The well system of claim 10, wherein the adhesive layer comprises anadhesive selected from the group consisting of natural rubber-basedadhesives, synthetic rubber-based adhesives, silicone adhesives,polyacrylate adhesives, pressure-sensitive adhesives, solvent basedadhesives, polymer dispersion adhesives, contact adhesives, and reactiveadhesives.
 19. The well system of claim 10, wherein the wear-resistantcoating is arranged in laterally-spaced strips on the front surface ofthe substrate.
 20. The well system of claim 10, further comprisingmultiple lengths of the wellbore tape, each length of the wellbore tapebeing configured to secure the control line to the conveyance atcorresponding discrete locations along an axial length of theconveyance.